US20030098163A1 - Flow actuated valve for use in a wellbore - Google Patents
Flow actuated valve for use in a wellbore Download PDFInfo
- Publication number
- US20030098163A1 US20030098163A1 US09/995,842 US99584201A US2003098163A1 US 20030098163 A1 US20030098163 A1 US 20030098163A1 US 99584201 A US99584201 A US 99584201A US 2003098163 A1 US2003098163 A1 US 2003098163A1
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- United States
- Prior art keywords
- valve
- fluid
- plunger
- wellbore
- tubular
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- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16K—VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING
- F16K3/00—Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing
- F16K3/30—Details
- F16K3/34—Arrangements for modifying the way in which the rate of flow varies during the actuation of the valve
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T137/00—Fluid handling
- Y10T137/7722—Line condition change responsive valves
- Y10T137/7837—Direct response valves [i.e., check valve type]
- Y10T137/7854—In couplings for coaxial conduits, e.g., drill pipe check valves
- Y10T137/7857—Valve seat clamped between coupling elements
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- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- General Engineering & Computer Science (AREA)
- Lift Valve (AREA)
- Preventing Unauthorised Actuation Of Valves (AREA)
Abstract
Description
- 1. Field of the Invention
- The present invention relates to a flow actuated valve for use in a wellbore. More particularly, the invention relates to a flow-actuated valve that is initially retained in an open position and is closeable with the application of fluid flow. More particularly still, the invention relates to a flow-actuated valve for use in float equipment to facilitate the injection of zonal isolation fluids into an annular area between a string of casing and a surrounding formation.
- 2. Description of the Related Art
- Hydrocarbon wells are conventionally formed one section at a time. Typically, a first section of wellbore is drilled in the earth to a predetermined depth. Thereafter, that section is lined with a tubular string, or casing, to prevent cave-in. After the first section of the well is completed, another section of well is drilled and subsequently lined with its own string of tubulars, comprised of casing or liners. Each time a section of wellbore is completed and a section of tubulars is installed in the wellbore, the tubular is typically anchored into the wellbore through the use of wellbore zonal isolation fluids, i.e. cementing. Wellbore zonal isolation fluids includes, but not limited to, the injection of cement into an annular area formed between the exterior of the tubular string and the borehole in the earth therearound. Zonal isolation protects the integrity of the wellbore and is especially useful to prevent migration of hydrocarbons towards the surface of the well via the annulus.
- Zonal Isolation of strings of tubulars in a wellbore is well-known in the art. Typically, the zonal isolation fluid is initially inserted in the tubular, and then forced to the bottom of the well and up the annular area toward the surface. With the use of other fluids, a column of zonal isolation fluids can be forced down the tubular string and into the annulus, resulting in a completely isolated annulus and leaving only a small amount of zonal isolation fluid at the bottom of the borehole. The cured fluid is drillable and is easily destroyed by subsequent drilling to form the next section of wellbore.
- Float shoes and float collars facilitate zonal isolation procedures. In this specification, a float shoe is a valve-containing apparatus disposed at or near the lower end of the tubular string that is run into in a wellbore. A float collar is a valve-containing apparatus which is installed at some predetermined location, typically above a shoe within the tubular string. In certain cases, float collars are required rather than float shoes. However, in this specification, the term float shoe and float collar will be used interchangeably.
- The main purpose of a float shoe is to facilitate the passage of zonal isolation fluids from the tubular to the annulus of the well while preventing the zonal isolation fluids from returning or “u-tubing” back into the tubular due to gravity and fluid density of the liquid zonal isolation fluids. In its most basic form, the float shoe includes a one way valve permitting fluid to flow in one direction through the valve, but preventing fluid from flowing back into the tubular from the opposite direction. The float shoes usually include a cone-shaped body to prevent binding of the tubular string during run-in.
- As mentioned, wellbores are typically full of fluid to protect the drilled formation of the borehole and aid in carrying out cuttings created by a drill bit. When a new string of tubulars is inserted into the wellbore the tubulars must necessarily be filled with fluid to avoid buoyancy and equalize pressures between the inside and the outside of the tubular. For these reasons, a float shoe can be capable to temporarily permit fluid to flow inwards from the well bore as the tubular string is run into the wellbore and fills the tubular string with fluid. In one simple example, a spring loaded, normally closed, one-way valve in a float shoe is temporarily propped in an open position during run-in of the tubular by a wooden object which is thereafter destroyed and no longer affects the operation of the valve.
- Other, more sophisticated solutions have been used that temporarily hold the valve in an open position and subsequently permit it to close and operate as a normally closed, one way valve. In a prior art arrangement, a valve is temporarily held in an open position during run-in and, thereafter, a weighted ball is dropped from the surface. The ball sinks to a seated position within the valve of a float collar and then, with pressure applied from the surface of the well, the valve is then enabled to shift to its normally closed position. In another prior art solution, a spring-loaded plunger is moved from an open position to a closed position utilizing hydrostatic pressure. The design utilizes an atmospheric chamber and shears screws. The number of shear screws determines the trip point of the device. As the tubular string is run deeper into a wellbore, hydrostatic pressure builds until it generates sufficient force on the shear screws to cause them to fail. The shearing action releases the plunger converting the valve to a normally closed, one-way valve.
- More recently, spring loaded plunger valves in float shoes have been moved from a retained open position with the flow of fluid. The existing designs use energy from wellbore fluid that is circulated with pumps through the valve to depress the plunger and subsequently trip the device. These devices are typically comprised of some form of stop which temporarily retains the valve in an open position. Typically, wedges, tabs, balls, or knobs are mechanically lodged between the plunger and its retainer. These hold the plunger open against the spring force. When sufficient flow is established, the plunger moves downward, compressing the spring further and releasing the wedged stops.
- There are problems associated with the prior art devices. Particularly, these devices are susceptible to premature release of the mechanism retaining the valve in an open position. For example, devices requiring a burst of fluid flow for deactivation can sometimes operate prematurely due to naturally occurring flow increases. Devices using an atmospheric chamber sometimes fail to operate as designed due to either design flaws or changes in well bore fluid density. If the valve releases premature, it is no longer possible to fill the tubular string with fluid from below. Because the tubular string must necessarily be filled with fluid to prevent pressure collapse and buoyancy, fluid must then be introduced from the surface of the well, thereby increasing the already high cost of completing drilled sections of wells.
- The present invention generally relates to a flow-actuated valve for use in a wellbore. The invention includes a body having a closing member and a seat. The closing member and seat are separable to open and close the valve, thereby allowing the flow of fluid through the valve. The invention further includes a retainer to initially retain the valve in the open position absent a predetermined fluid flow rate in one direction for a predetermined time period. A biasing member thereafter urges the valve to the closed position, absent another fluid flow rate in one direction.
- So that the manner in which the above recited features of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
- FIG. 1 is a perspective view of a valve of the present invention.
- FIG. 2 is an exploded view of the valve of FIG. 1.
- FIG. 3 is a section view of the valve of FIG. 1, with a retention assembly retaining the valve in an open position.
- FIG. 4 is a section view of a wellbore with a valve of the present invention disposed in a tubular.
- FIG. 5 is a section view of the valve of FIG. 4 as the retention assembly is being deactivated.
- FIG. 6 is a section view of the valve operable as a one way, normally closed valve.
- FIG. 7 is a section view of the valve operating to permit fluid to flow from its upper end to and through its lower end.
- FIG. 8 is a section view showing an alternative embodiment of the valve with a retention assembly activated.
- FIG. 9 is a section view of the valve of FIG. 8 with the retention assembly deactivated.
- FIG. 1 is a perspective view of a
valve 100 of the present invention. Visible in FIG. 1 is anupper housing 105 and a lower 110 housing. Also visible is animpeller 120 partially extending from thelower housing 110. In use, thevalve 100 is disposed in the interior of a tubular string (not shown) in a manner whereby all fluid passing through the tubular in either direction must flow through thevalve 100. In one example, thevalve 100 is disposed at a lower end of a tubular string. In another example, thevalve 100 is disposed at some location within the tubular apparatus, such as in a collar within a string of casing. - FIG. 2 is an exploded view of the
valve 100 of FIG. 1. Visible in FIG. 2 are the upper 105 and lower 110 housings. Theupper housing 105 includes anaperture 107 formed therethrough with a seat (not visible) formed in an interior surface thereof. Additional components of thevalve 100 are substantially housed between the upper 105 and lower 110 housings. Aplunger 125 with ahead portion 127 and a sealingmember 130 therearound creates a sealing relationship between theplunger 125 and thevalve body 105 when thevalve 100 is closed. The sealing member, therefore blocks the inward flow of fluid ofvalve 100 as fluids attempt to enter the tubular string. Theplunger 125 includes ashaft 135. A biasing member, in this case aspring 140, is locatable between thehead 127 of theplunger 125 and asurface 142 formed in asupport member 145. Thespring 140 is constructed and arranged to become compressed as thehead 127 of the plunger moves away from theupper housing 105. In this manner,valve 100 is biased in a closed position. Thesupport member 145 also includes a fluid path therethrough with radially disposedspokes 147 extending between an inner and an outer portion. Below thesupport member 145 is anannular diverter 150 for diverting the flow of fluid through the valve as is illustrated in FIGS. 3-7. - The valve of the present invention also includes a
retention assembly 200. Theretention assembly 200 serves to temporarily hold thevalve 100 in an open position. The open position is especially useful to permit a tubular string to fill with fluid during run-in into a wellbore. Theretention assembly 200 operates by holding theplunger head 127 away from the seat in theupper housing 105 until a sustained fluid flow rate is applied through thevalve 100 in a forward direction. Typically, the forward direction is a downward direction. A partially threadedbolt 205 having ahead 206 at an upper end is insertable into a hollow portion of theshaft 135 of theplunger 125. Asleeve 210 is attachable to thebolt 205 and is extendable through a body of animpeller 120, where it is retained at a bottom end thereof with afastener 222. Theimpeller 120, as will be described, includeblades 122 formed on a body thereof to urge theimpeller 120 to rotate as the blades are acted upon by a fluid flow. Thebolt 205 and the upper portion ofsleeve 210 are held within the plunger shaft by abushing 215 having threads on an inner and outer diameter. Therelease assembly 200 is designed whereby the bolt and sleeve will rotate with theimpeller 120 while thebushing 215 and theplunger 125 will remain rotationally fixed. In this manner, axial movement of the impeller and bolt is transmitted by the interaction of the threads of thebolt 205 and thebushing 215. - FIG. 3 is a section view of the
valve 100 with theretention assembly 200 retaining the valve in an open position. Visible in the figure is anaperture 107 in an upper end ofupper housing 105. In the interior of thehousing 105 isseat 109 providing a sealing surface for the sealingmember 130 of theplunger 125. In the retained position, thespring 140 is compressed between anannular surface 217 formed on the underside of theplunger head 127 andannular surface 142 ofsupport member 145. Theretention assembly 200 operates to holdplunger 125 in the position of FIG. 3 through a mechanical connection betweenbushing 215 andbolt 205. As illustrated, thebushing 215 is held in the lower end of theshaft 135 ofplunger 125 while thebolt 205 is held within thesleeve 210. The threaded connection between thebushing 215 and thebolt 205 determines the relative position of theplunger head 127 with respect to theseat 109. -
Impeller 120 withblades 122 is retained between anunderside 220 ofsupport member 145 andfastener 222 threaded to a lower end of thesleeve 210. The purpose of theimpeller 120 is to rotate in one of two directions depending upon the flow force of fluid past itsblades 122. Because thebolt 205 moves with theimpeller 120, rotation of theimpeller 120 in either direction will cause relative axial movement between thebolt 205 and thebushing 215. - FIG. 4 is a section view of the
valve 100 illustrating the flow of fluid through thevalve 100 indirection 225. As previously described, thevalve 100 is typically disposed in the bottom end of thetubular string 101 which is then run into awellbore 102 having drilling fluid therein. One purpose of thevalve 100 is to initially permit fluid to pass from a lower to an upper portion of thevalve 100 as thetubular string 101 is being lowered into thewellbore 102.Arrow 224 illustrates the movement of thetubular string 101 in relation to thewellbore 102. Thereafter, theretention assembly 200 of thevalve 100 is deactivated, and thevalve 100 operates as a normally closed, one-way valve permitting fluid to pass from an upper to a lower portion. - In FIG. 4, the
valve 100 is illustrated in a run-in position with theretention assembly 200 activated. As illustrated, thehead 127 ofplunger 125 is separated fromseat 109 formed in theupper housing 105 of thevalve 100. As illustrated witharrows 225, fluid flows from a lower end of thevalve 100 through an annular area formed in thevalve 100 between theplunger 125 and the upper 105 and lower 110 housing portions. Also illustrated byseparate arrow 226 is a rotational force applied to theimpeller 120 by fluid movingpast blades 122 ofimpeller 120. In the illustration of FIG. 4, the fluid flow indirection 225 acts on theimpeller blades 122 urging theimpeller 120 to rotate in a clockwise direction. However, due to high frictional forces, rotation is prohibited. - FIG. 5 is a section view of the
valve 100. In FIG. 5, theretention assembly 200 is being deactivated and the flow of fluid through thevalve 100 is illustrated byarrows 230. Thearrows 230 illustrate fluid being pumped from an upper end of thevalve 100 through an annular area defined between the outer surface of theplunger 125 and the inner surface of the upper 105 and lower 110 housings. In FIG. 5, the flow of fluid acting on the upper surface ofplunger head 127 has depressed theplunger 125 and compressed thespring 140 further than it was originally compressed during run-in. The additional compression of thespring 140 and downward movement ofplunger 125 has caused a corresponding downward axial movement of theimpeller 120. An underside 220 ofsupport member 145 is shown separated from the upper surface of theimpeller 120. The result of this separation is greater freedom of theimpeller 120 to rotate as the fluid moves across itsblades 122. Of course, the scope of the present invention permits a design of thevalve 100 which does require the separation of thesupport member 145 from theimpeller 120 before rotation of theimpeller 120. - In order to initiate the release of the
retention assembly 200 of FIG. 5, two conditions are created simultaneously. First, theplunger 125 is depressed past its originally retained position in order to separate theimpeller 120 from thelower surface 220 ofsupport member 145, making it easier for the impeller to rotate. Second, theimpeller 120 must be rotated by fluid passing across the from an upper to a lower portion of thevalve 100. The rotation of theimpeller 120 with thebolt 205, indirection 227, will cause the threaded portion of thebolt 205 to move downward in relation to thebushing 215. As theimpeller 120 continues to rotate, that portion of thebolt 205 which is threaded will pass through the bushing, allowing thebolt 205 to then slide freely within thebushing 215 after its threads are disengaged therefrom. - FIG. 6 is a section view of the
valve 100 disposed in atubular string 101 which is itself disposed in awellbore 102. FIG. 6 illustrates thevalve 100 with theretention assembly 200 deactivated. As illustrated,bushing 215 is adjacent a portion of thebolt 205 having no threads on its outer diameter.Bolt 205 has slipped through the bushing to a location wherebyhead 206 of the bolt is retained on an upper surface of thebushing 215. The axial movement of thebolt 205 with respect tobushing 215 has permitted theplunger 125 with its sealingmember 130 to contactseat 109 formed in the underside ofupper housing 105. In this manner, thevalve 100 is sealed to the flow of fluid from below, and will only permit fluid entry from above if the fluid flow is adequate to overcome the bias ofspring 140. Theretention assembly 200 has thus been permanently disengaged and thevalve 100 can now operate as a typical float shoe valve permitting zonal isolation fluids to flow through thevalve 100 from the surface downhole, but preventing a back flow of the zonal isolation fluids into thetubular string 101. - FIG. 7 is a section view of
wellbore 102 withvalve 100 intubular string 101. FIG. 7 illustrates thevalve 100 in use with zonal isolation fluids such as cement being pumped from an upper end of the tubular, through thevalve 100, to the lower end of thewellbore 102. The movement of theplunger 125 downward is shown witharrow 229. The flow of fluid is illustrated witharrows 228. As illustrated by thearrows 228, zonal isolation fluids enters thevalve 100 from an upper end and acts uponplunger head 127 to depress theplunger head 127 and to unseat sealingmember 130 fromseat 109 ofupper housing 105.Spring 140 is shown in a somewhat compressed position. The fluid flows through the valve and the annular area created by the inside of the upper andlower housings plunger 125. Thereafter, the fluid is guided arounddiverter 150 and exits through the lower end of thevalve 100. Any effect the passing fluid may have on theblades 122 of theimpeller 120 is unimportant as the impeller is free to rotate without creating any change in thevalve 100. This is because the threads of thebolt 205 have now been released from thebushing 215. From the bottom of the tubular, the zonal isolation fluids flow upward to fill anannular area 103 formed betweentubular 101 andwellbore 102. At some predetermined point, when theannulus 103 is filled with zonal isolation fluids, the flow of zonal isolation fluids is stopped and the fluids are allowed to cure. Thereafter, the cement shoe, including thevalve 100 can be drilled up and destroyed by subsequent drilling of another section of wellbore. - In use, the
valve 100 of the present invention is utilized as follows: - The
valve 100 is disposed either at the end or near the end of a tubular 101, such as a casing or liner string. Thetubular string 101 with thevalve 100 disposed therein is run into awellbore 102 with theretention assembly 200 of the valve holding it in an open position. In this manner, as thetubular string 101 is inserted into thewellbore 102, wellbore fluid is free to pass from a lower to an upper end of thevalve 100, thereby permitting the tubular 101 to fill with fluid. - After the tubular string reaches a predetermined point in the well, wellbore fluid or some other fluid is pumped through the
valve 100 at apredetermined flow rate 140. The injection of fluid under pressure further depresses theplunger head 127 and further compresses the biasingspring 140. In this manner, theimpeller 120 disposed at the bottom of thevalve 100 is separated from its contact with the surface of thesupport member 145 and is free to rotate. Simultaneously, the fluid utilized to depress the plunger urges theimpeller 120 to rotate. The rotation of the impeller indirection 227 causes the threads of thebolt 205 and thebushing 215 to transmit motion of thebolt 205 in a downward direction with respect to thebushing 215. As that portion of thebolt 205 having threads pass through thebushing 215, a non-threaded portion of thebolt 205 permits thebolt 205 to drop to a lower position with respect to thebushing 215 and to be retained in thebushing 215 bybolt head 206. In this position, theretention assembly 200 is deactivated and thevalve 100 operates as a normally closed, spring loaded, one-way valve for cementing operations in a wellbore. - FIG. 8 is a section view illustrating an alternative embodiment of the invention. The
valve 300 of FIG. 8, like the earlier embodiments includes a spring-loadedplunger 325 and animpeller 320 attached to the plunger by a threaded member. In the embodiment of FIG. 8, abushing 315 is disposed in the interior of theimpeller 320 and an interior of theplunger shaft 335 is threaded. A partially threadedbolt 305 is threaded into the plunger shaft at an upper end and is also threaded through thebushing 315. FIG. 8 illustrates thevalve 300 in an initial position in which ahead 327 of theplunger 325 is biased againstspring member 340 thereby opening the valve to flow therethrough. Thebolt 305 also includes a lower end havingadditional threads 306 formed thereupon and anut 307 retained on the threads. - In operation, the
valve 300 of FIG. 8 operates as follows: During run-in of a string of tubulars into the wellbore the valve permits the tubular string to fill with fluid. Thereafter, theretention assembly 400 made up of theimpeller 320 andbolt 305 is caused to deactivate by the flow of fluid on theplunger head 327 at a specific rate and for a predetermined amount of time. As with the earlier embodiment, the flow of fluid causes theplunger head 327 to move downwards against thespring 340 and permits theimpeller 320 to move out of engagement with asupport member 145. With the impeller out of engagement,blades 322 formed on the impeller cause it to rotate in a counterclockwise direction and thebushing 315 andimpeller 320 rotate and move axially away from theplunger shaft 335. As the rotating threads of thebushing 315 reach a portion of the bolt which is unthreaded, the bushing and impeller drop to a second position in relation to thebolt 305. As the impeller continues to rotate in a counterclockwise direction it becomes threadedly attached to thethreads 306 at the lower portion of thebolt 305 and is prevented from additional rotation. The threaded portion at the lower end of the threaded member is designed to prevent the impeller from rotating after theretention assembly 400 is deactivated in order to prevent any damage that might come about due to the freely rotating impeller. - FIG. 9 is a section view of the
valve 300 illustrating the components of thevalve 300 after theretention assembly 400 has been deactivated. Theplunger 325 is in its normally closed, spring biased position and theimpeller 320 is threaded at a lower end of thebolt 305, thereby preventing additional rotation of theimpeller 320. - While the valve of the present invention has been described with the use of an impeller which is rotated by the flow of fluid, it will be understood that the invention could use any type of rotatable member to deactivate the retention assembly and the invention is not limited to the use of an impeller having blades to be acted upon by a passing fluid flow. For instance, the rotatable member could be rotated by a downhole motor, a spring or anything else to translate the rotatable member along the threads of another member to deactivate a retention assembly. These variations are fully within the scope of the invention.
- While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow. For example, the
retention assembly 200 could be used with various valve devices including flapper valves and the invention is not limited to use with plunger-type valves.
Claims (11)
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
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US09/995,842 US6622795B2 (en) | 2001-11-28 | 2001-11-28 | Flow actuated valve for use in a wellbore |
GB0411876A GB2399370B (en) | 2001-11-28 | 2002-11-22 | Flow actuated valve for use in a wellbore |
CA002468899A CA2468899C (en) | 2001-11-28 | 2002-11-22 | Flow actuated valve for use in a wellbore |
AU2002365709A AU2002365709A1 (en) | 2001-11-28 | 2002-11-22 | Flow actuated valve for use in a wellbore |
PCT/GB2002/005404 WO2003048509A1 (en) | 2001-11-28 | 2002-11-22 | Flow actuated valve for use in a wellbore |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US09/995,842 US6622795B2 (en) | 2001-11-28 | 2001-11-28 | Flow actuated valve for use in a wellbore |
Publications (2)
Publication Number | Publication Date |
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US20030098163A1 true US20030098163A1 (en) | 2003-05-29 |
US6622795B2 US6622795B2 (en) | 2003-09-23 |
Family
ID=25542268
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US09/995,842 Expired - Lifetime US6622795B2 (en) | 2001-11-28 | 2001-11-28 | Flow actuated valve for use in a wellbore |
Country Status (5)
Country | Link |
---|---|
US (1) | US6622795B2 (en) |
AU (1) | AU2002365709A1 (en) |
CA (1) | CA2468899C (en) |
GB (1) | GB2399370B (en) |
WO (1) | WO2003048509A1 (en) |
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US11242719B2 (en) * | 2017-11-27 | 2022-02-08 | Chevron U.S.A. Inc. | Subterranean coring assemblies |
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- 2001-11-28 US US09/995,842 patent/US6622795B2/en not_active Expired - Lifetime
-
2002
- 2002-11-22 AU AU2002365709A patent/AU2002365709A1/en not_active Abandoned
- 2002-11-22 WO PCT/GB2002/005404 patent/WO2003048509A1/en not_active Application Discontinuation
- 2002-11-22 GB GB0411876A patent/GB2399370B/en not_active Expired - Fee Related
- 2002-11-22 CA CA002468899A patent/CA2468899C/en not_active Expired - Lifetime
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US8342251B2 (en) | 2007-01-19 | 2013-01-01 | Tercel Oilfield Products Uk Limited | Shoe for wellbore lining tubing |
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US9347286B2 (en) | 2009-02-16 | 2016-05-24 | Pilot Drilling Control Limited | Flow stop valve |
US20110100471A1 (en) * | 2009-10-30 | 2011-05-05 | Hydril Usa Manufacturing Llc | Drill String Valve and Method |
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US10435984B2 (en) | 2014-08-12 | 2019-10-08 | Halliburton Energy Services, Inc. | Float valve with resettable auto-fill |
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RU171799U1 (en) * | 2017-03-28 | 2017-06-16 | Общество с ограниченной ответственностью "Русская электротехническая компания" ("РУСЭЛКОМ") | CHECK VALVE MODULE |
RU193563U1 (en) * | 2019-08-13 | 2019-11-05 | федеральное государственное бюджетное образовательное учреждение высшего образования "Пермский национальный исследовательский политехнический университет" | CHECK VALVE |
US11231118B1 (en) * | 2020-11-10 | 2022-01-25 | Hanon Systems | Integrated one way valve |
US20230069930A1 (en) * | 2021-09-07 | 2023-03-09 | Downhole Products Limited | Dual flow converted auto-fill float valve |
Also Published As
Publication number | Publication date |
---|---|
GB2399370B (en) | 2006-04-05 |
CA2468899C (en) | 2007-09-18 |
GB0411876D0 (en) | 2004-06-30 |
WO2003048509A1 (en) | 2003-06-12 |
US6622795B2 (en) | 2003-09-23 |
AU2002365709A1 (en) | 2003-06-17 |
CA2468899A1 (en) | 2003-06-12 |
GB2399370A (en) | 2004-09-15 |
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